monitoring update sample

SO₃ in the flue gas stream from a fossil-fueled boiler has long been a concern for plant operators because of the potential for fouling and corrosion in the air heater and corrosion in ducts and equipment downstream caused by the sulfuric acid formed from the SO₃. Excessive SO₃ in emissions from the stack can also cause opacity (blue plume) and acid mist deposition problems. In addition, the presence of SO₃ adversely affects the removal of mercury from the flue gas with ACI. The affect of SO₃ aerosols on particulate emissions has also been a concern - more so in some plants than others.

But SO₃ in flue gas will soon be a much bigger concern for all. Because SO₃ contributes to the formation of condensable or fine particle emissions, the recent changes in the National Ambient Air Quality Standards (NAAQS) for particulates and ozone may force even greater control of SO₃ under local standards or under regulations dealing with particulates. The utility MATS with lower limits on mercury and SO₂ will further complicate the issue.

Control of SO₃ is a complex problem that can be highly dependent on the control technology utilized for NO_x, SO₂, mercury and particulates. In addition, measurement of SO₃ can be difficult which further complicates the control problem. In the March 8 Hot Topic Hour, five very knowledgeable speakers presented the current “state of the art” for SO₃ measurement and control.

James (Jim) C. Dickerman, Director of Flue Gas Treatment Applications at Lhoist North America (formerly Chemical Lime Company), presented an overview of SO₃ emission control with hydrated lime. He discussed the development history of the technology as well as the key design parameters that need to be considered for successful operations. Initial problems (primarily plugging of lances) were resolved and the technology is fully commercialized now with installations at over 30 utility boilers. Future development is focused on the control of other acid gases such as HCl and SO_2.He said they have demonstrated that hydrated lime can be injected downstream of the ESP (upstream of a scrubber) and not increase particulate emissions. Also, injecting hydrated lime at two locations is more effective than one location. Injection upstream of the air heater can reduce ABS formation with no downstream impacts.

James (Jim) B. Jarvis, Project Manager at URS Corp., stood in for Sterling Gray, Manager of SBS Injection Technology. He described the application of a liquid sodium based reagent (SBS) to reduce SO₃ and mercury emissions at power plants. He stated that since 2005 they have learned that injection of SBS upstream of the air preheater provides maximum benefits. Since 2005, they have had 24 boilers operating with upstream injection, some of which had downstream injectors relocated. They also have four installations ahead of the SCR that have been operating for three years. He stated that SBS injection can significantly reduce SO₃ levels prior to the air heater and reduce stack emissions of SO₃ to less than 1ppm and 0.003 lbs/MMBtu SAM. He presented a number of graphs showing that mercury capture rates of 50 to 90 percent can be achieved with high-efficiency SO₃ control and with little to no carbon injection.

Curtis (Curt) Laush, Ph.D., Senior Scientist at Industrial Monitor and Control Corp. (IMACC), described the capabilities, operation and field-testing of a CEM-type analyzer based on a quantum cascade laser (QCL) absorption spectrometer for real time continuous monitoring of SO₃ and SO₂ across flue gas ducts. The in-situ design eliminates sample extraction issues allowing a truly representative measurement of SO₂, SO₃ and water vapor with fast response (less than 1 minute) and high resolution (500 ppb in a 5 meter duct). In May IMACC will begin field-testing a second-generation instrument and expects to have it commercialized by the end of the year. Potential applications include tracking SO₂ oxidation in real time across catalysts and downstream, tracking potential SO₃ dew points when optimizing air heater operation and optimizing sorbent usage for SO₃ mitigation.

Dr. Yougen Kong, P.E., Technical Development Manager at Solvay Chemicals, Inc., discussed the interactions between SO₃, HCl, HBr, PM and Trona in flue gas. Trona injected before and after the air heater can be very effective at controlling acid gases as well as enhancing mercury removal. However, he emphasized that flue gas treatment at a coal-fired power plant has become a chemical processing plant and a solution for one plant may not fit another plant. Treating one component in the gas can affect the other components. Therefore to be successful, you must understand the chemistry of the gas, apply a systems approach and all suppliers of APC equipment and the design engineers must work closely together.

Jeff Socha, R & D Project Leader for the SO₃ CEMS at Thermo Fisher Scientific Air Quality Instruments described capabilities of and initial field test results for a dilution extractive SO₃ monitor being developed for real time monitoring of SO₃ in flue gas. The instrument uses a cascade laser and has an integrated SO₃ gas generator for daily calibrations and dynamic spiking to detect bias. The detection limit is 0.4 ppm. Two systems are currently undergoing beta evaluations at two power plants – one downstream of an FGD and one downstream of an ESP. An instrument with a 100-foot sample line has a response time of 19 minutes.

The entire March 8 recording can be heard at: SO3 Measurement & Control – 112 minutes – Password: hth881

The Hot Topic Hour on March 15 was about new ways to control mercury and to measure it. Sorbent traps were discussed as an alternative to CEMS. Three alternatives to activated carbon were claimed to be more cost effective.

Jim Wright, Director of Source Testing Mercury at Clean Air Engineering, Inc., discussed mercury measurement, specifically continuous monitoring at very low levels using sorbent trap technology. The sorbent trap can accurately measure very low mercury levels. It may be the only way to accurately measure at the levels mandated by New Source Performance Standards (NSPS). A number of sorbent trap systems are operating in states which now require monitoring. Utilities are replacing the traps themselves. Thus the operating costs are comparable to CEMS. The disadvantage is lack of process control. You only find out the results every hundred hours. But this device could be coupled with a CEMS if process control is also needed. The CEMS could be configured just for process intelligence without constraints about operation for compliance demonstration.

John Darrow, Associate, and Jeff Kolde of the Mercury Control Technology Team at W. L. Gore & Associates, Inc. described a new fixed-bed sorbent technology for controlling mercury emissions from combustion applications. This “end-of-pipe” solution provides a simple and effective way to continuously capture both elemental and oxidized mercury from flue gas streams for typically several years at a time without requiring regeneration. Drawbacks of activated carbon injection such as flyash contamination and interference by SO₃ are completely avoided. In addition to very high mercury removal efficiency, SO_x emissions are reduced as a co-benefit. Cost comparisons to activated carbon were provided. The Gore approach showed economic advantages in several cases analyzed. It appears to also be attractive as an add-on technology in case higher efficiencies are needed in the future. If a power plant is installing an FGD system, it can leave additional height above the mist eliminator for eventual installation of the Gore modules.

Bobby IT. Chen, Client Program Manager of Integrated Emissions Solutions at Shaw Environmental & Infrastructure Group, presented some very up-to-date information on the control of mercury from power plants burning lignite coal using a special brominated compound. He advised participants that

Marc Sylvester, Vice-president for Sales at Midwest Energy Emissions Corp (ME2C), discussed control of mercury emissions from major utility and industrial boilers utilizing patented technologies. ME2C has worked closely with the Energy & Environmental Research Center (EERC) at the University of North Dakota to develop and deploy cost effective mercury control technologies in the world. The technology combines enhancement additives with sorbents at two injection points. Details on performance at a 700 MW power plant were provided. 90 percent capture was achieved with enhancement additives of 0.3 lb/MACFM and sorbent of 1.2 lb /MACFM. Brominated activated carbon was only able to obtain 80 percent capture at 3.2 lb/MACFM. Another difference was that ME2C had no impact on flyash sales whereas the brominated activated carbon created an unsalable flyash.

At the March 22 Hot Topic Hour the following speakers helped us understand the current situation of the Industrial Boiler MACT and suggested how boiler operators might deal with the impact of the current and proposed rule.

Connie Senior, Director of Technology Development ADA Environmental Solutions, discussed “Low Capex Solutions for Compliance with Industrial Boiler MACT.” Integration of sorbent injection with particulate control can provide control of both mercury and HCl, if care is taken to select the right sorbents and design the system correctly. Often a combination of alkaline sorbents and activated carbon injected separately may be the best answer.

Katherine (Kate) L. Vaccaro, Associate at Manko, Gold, Katcher & Fox LLP, focused on some of the key aspects of EPA's Proposed Reconsideration of the Boiler MACT, including certain relevant compliance deadlines. She highlighted some of the principal concerns voiced by industry in response to EPA's proposal. Many of these have been addressed in the most recent revisions. However, when EPA issues the final reconsideration next month, there is likely to be further challenge from industry.

David South, President of Technology & Market Solutions, LLC, a consulting firm, discussed some compliance activities boiler operators could be doing now. While Boiler MACT emission reduction requirements and schedule are still uncertain, the rulemaking specifies several compliance activities that are less contentious and would improve boiler operations regardless of the ultimate emission requirements. Tune-up steps include:

Mack McGuffey, Partner at Troutman Sanders LLP Atlanta office and a specialist in regulatory compliance under the Clean Air Act, reviewed history which shows that there have been substantial changes in the proposed limits each time the proposed rule has been revised. He speculated that some more changes are likely to be reflected in the newest version. But here are some changes in the present version from the previous.

Reconstructed boilers cost over 50 percent of the cost of a comparable new source and are technically and economically feasible to meet standards.

As of now, the final rules published on March 21, 2011, are fully effective, with a compliance date of May 21, 2014. That rule requires continuous emission monitoring systems (CEMS) to demonstrate compliance with CO and PM standards, as follows:

Key: Major Source: Potential to emit ≥ 10 tons/year of a single HAP, or ≥ 25 tons/year combined of all HAPs

Area Source: A boiler which doesn’t qualify as a major source, but has a design heat rate input capacity of 10 MMBTU/hr or more

As indicated in the timeline above, EPA published proposed changes to the rule in December 2011 and accepted until February 2012. When a new, final, revised rule is issued later this year, is it likely to change any of the continuous monitoring requirements summarized in Figure 1? For particulate matter, the answer is probably no. Monitoring requirements for PM remained essentially the same from the proposed to the final rule and no changes were suggested in the re-proposal.

With respect to CO monitoring at major sources, however, changes are likely. Monitoring requirements for CO changed from CO CEMS to O₂ CEMS from the proposed to the final rule, as summarized in Figure 2. In re-proposing the rule, EPA acknowledged concerns about oxygen monitors placed in a boiler’s exhaust due to air stratification issues. The December 2011 reconsideration proposal says that “a better way” to ensure good combustion is to require the use of an oxygen trim system to optimize the air to fuel ratio and combustion efficiency. A typical trim system consists of a flue gas oxygen or carbon monoxide monitor with an automatic feedback signal to the combustion air controller.

Figure 2. ICI BOILER MACT - Evolving Continuous Monitoring Requirements for CO

Due to tighter regulations, coal-fired power plants around the world are retrofitting air pollution control equipment. In addition, there are many new coal-fired power plants in Asia that are being equipped with the latest air pollution control technologies. The result is thousands of current projects amounting to more than $30 billion. Each of these projects is reported in the McIlvaine Utility Environmental Upgrade Tracking System.

The U.S. activity is reaching a new peak due to the recent Mercury and Air Toxics Standard (MATS). Large numbers of fabric filters and dry injection systems to capture HCl and SO₂ are in the planning stage with compliance due in just three years.

A number of projects are also under way in Europe. Eastern Europe is very active. Serbia has FGD and NO_x projects in construction and planning along with electrostatic precipitator upgrades.

Most of the activity in India involves new coal-fired boilers. Plants with three or more large boilers with combined capacities up to 4000 MW are being initiated. Contracts for three new coal-fired power plants with air pollution control equipment have just been ordered in Indonesia. These coal-fired power plants will total over 2000 MW. Pakistan is also continuing to build coal-fired power plants. A number of projects are under way in Vietnam.

The leading country in terms of projects and investment is China. Orders for new coal-fired power plants are averaging 3000 MW per month. Typically, these are large ultrasupercritical boilers with electrostatic precipitators, selective catalytic reduction systems and wet limestone flue gas desulfurization.

The companies participating in this market are becoming more geographically diverse. Chinese companies have dominated the electrostatic precipitator market for more than a decade. However, most of the sales by these companies have been in Asia. Alstom has maintained a lead in the rest of the world.

Most of the Chinese FGD systems have been built under license from Japanese, European and U.S. companies. Some Chinese companies are now supplying their own designs. In fact, one Chinese company has licensed its dry scrubbing technology to Marsulex for application in the West. Marsulex has long been a licensor of wet FGD technology in China.

The ranking of the suppliers in Europe has changed substantially in recent years primarily due to restructuring of some of the companies. Doosan Power and Andritz are now active in FGD through acquisitions.

Worldwide sales of scrubbers, absorbers, adsorbers and biofilters will grow at a 7 percent CAGR over the next five years due largely to new technologies and applications as opposed to new regulations impacting existing applications. This is the latest finding in “Scrubber/Adsorber/Biofilter World Markets” published by the McIlvaine Company.

Industry	2012
Chemical	733
Electronics	159
Food	188
Incinerators	1,394
Metals	760
Other Industries	900
Pulp & Paper	296
Surface Coating	654
Wastewater	1,228
Total	6,312

In 2012, 14 percent of the market will be in a miscellaneous “other industries category.” However, over the next five years this is the category which will see the biggest growth. In 2015, large vessels will either have to install scrubbers or greatly reduce the sulfur in the fuel they burn. The economics dictate the scrubber option. Scrubbers for vessels will be a big enough market to rank higher than pulp and paper, food, and electronics.

Another new application is the cement industry. New air toxic regulations in the U.S. will require retrofitting scrubbers on many plants. Some plants in Europe and Asia will install scrubbers.

New technologies will also boost scrubber revenues at the expense of some other types of equipment. Market share will be taken away from the selective catalytic reduction systems used for NO_x control as scrubbers using ozone capture some of the market. Ozone converts NO_x to a soluble NO₂ which can be captured in scrubbers. Ozone will also be increasingly used in combination with scrubbers to compete with carbon adsorbers and biofilters for odor removal from municipal wastewater and food plant stacks.

In the 1960 to 2000 period, the scrubber market was largely driven by the regulations in Europe and the U.S. which required existing plants to install equipment. This program has been completed but now there is a large investment in new plants in Asia. This includes waste-to-energy plants, steel mills, chemical plants and municipal wastewater treatment plants, so the market in Asia is already larger than other regions and will continue to grow at a faster pace.

We cannot afford to wait for so-called “Clean Coal.” We need a strategy which moves us forward to cleaner coal now. We should immediately start building ultra-supercritical, highly efficient, low polluting coal-fired power plants to replace the oldest and least efficient existing power plants. This is the key first step toward progressive and opportunistic cleaner energy.

There are too many uncertain variables for the U.S. and the world to set rigid strategies and time tables. The course recommended in the McIlvaine publication, “Fossil & Nuclear Power Generation: World Analysis & Forecast” is labeled “Progressive and Opportunistic Cleaner Energy.”

Sometime within the next 100 years, the fossil fuels will be depleted, while solar and other renewable technologies will be advanced to the point at which they can supply the world’s electricity. Long before fossil fuels are depleted, there will be a priority to convert them to liquid fuels. Even now it is less expensive to make gasoline from U.S. coals than to import oil at $100/barrel and refine it. If shale gas is plentiful, it would also make sense to convert it to gasoline rather than use it in power generation.

“Clean Coal” has been viewed narrowly as incorporating carbon capture and sequestration. However, there are several other equally important factors. One is conversion efficiency. It is possible to greatly reduce CO₂emissions per unit of electricity produced by use of advanced ultra-supercritical technology. Another is emission control. Coal-fired units can be fitted with pollution control equipment to remove 99 percent of the pollutants (particulate, acid gases, toxic metals and NO_x).

A third factor contributing to cleaner coal is resource synergy. The large steam plume from the coal-fired power plant cooling tower is testimony to the wasted heat which could be better used to operate fish farms, grain driers, ethanol plants and any operation needing low pressure steam.

Another resource synergy has to do with fuels. If cellulosic ethanol becomes commercialized, there will be large quantities of waste biomass which can substitute for a portion of the coal. Sewage sludge and garbage can be gasified and used as “reburn” fuels in coal-fired boilers. High chlorine coals present the opportunity to make 30 percent hydrochloric acid and eliminate the pollution associated with alternative production methods.

The conclusion is that the cleanliness of coal is defined holistically to be the net emissions taking into account carbon capture, efficiency, emission capture and resource synergy. Carbon capture can be a follow on investment. Initially the focus should be on efficiency, emission capture and resource synergy.

Carbon capture and sequestration will only make sense when utilized on highly efficient boilers. Why not build the ultra-supercritical, ultra low emission units now, and then equip them with carbon capture at a later date? Ironically, the Chinese and the Indians are already on this track, while the U.S. is only doing the research.

Due to anomalies in the legal system, environmental advocates have become their own worst enemy. By resisting the construction of any new plant, they will cause 285 GW of old coal-fired power plants to still be operating in 2035. This is the conclusion of the new EIA forecast.

Fuel	Capacity GW in 2035
Coal	285
Gas	408
Nuclear	112
Renewables	168
Other	27
Total	1,000

If these power plants were replaced by ultra-supercriticals, they would use 20 to 30 percent less coal and generate 20-30 percent less CO₂ while emitting only 10 percent of the pollutants emitted by the old power plants.

Cost is a dominant factor in the opportunistic progressive strategy. The replacement of old coal-fired power plants with new ultra-supercriticals will be extremely cost effective. They are using 20-30 percent less coal and are 20 to 30 percent smaller than the power plants they replace. With modern control systems, they are easier to operate and maintain. As a result, the replacement can be justified with just a 25 year expected life for the new ultra-supercritical.

At the end of the 25 years, carbon capture and sequestration can be added or the plant replaced with wind or solar generators. In any case, the reduction in emissions for the next 25 years will be achieved at virtually no cost.

An ultra–supercritical coal-fired power plant burning 20 percent biomass, providing steam for synergistic industrial uses and equipped with 90 percent carbon capture, would actually be a net carbon reducer, so this would be the cleanest energy. The best solar and wind would at best be carbon neutral.

The market for stack continuous emissions monitors (CEMS) will be just under $1 billion this year. Ambient continuous emissions monitoring plus stack testing will add another $1.5 billion, bringing the total to $2.5 billion in 2012. This is the latest forecast in “Air Pollution Monitoring & Sampling World Markets,” an online publication of the McIlvaine Company.

East Asia will be the biggest market for stack CEMS. The reason is the large number of new coal-fired boilers, cement plants, incinerators and other industrial plants which are under construction. This region will also account for the majority of the new ambient monitoring systems. Many developing countries are prioritizing investments to measure the levels of air pollution.

The U.S. market is being boosted by new air toxic regulations affecting utility coal-fired boilers, cement plants and industrial boilers. Dedicated CEMS will be required to measure hydrogen chloride, mass particulate and mercury. An alternative to measuring total particulate will be the measurement of a number of individual toxic metals. A commercial option to accomplish this has just been introduced by Pall.

The stack testing market is still centered in the developing countries. The investment in periodic calibration of CEMS systems is growing substantially as new CEM types are incorporated. Testing for mercury is a complex task. The result is that only a few companies are able to offer this service.

There is a rapidly growing market at the interface between emission and process monitoring. The stringency of regulations dictate that the processes operate within the emission limits. The CEMS become a critical tool in adjusting operations to insure compliance. Equally important are the use of CEMS to optimize the expenditures for chemicals. Expensive sorbents such as activated carbon and other chemicals such as ammonia need to be injected. CEMS at the inlet and outlet of air pollution control equipment can be used to fine tune the chemical additions and save considerable costs for excess chemicals.

Many of the suppliers of air monitoring instrumentation and systems also supply water quality instrumentation.

Horiba is a strong player in stack gas continuous emissions monitor and has significant sales in Asia, North America and Europe. It is the leading supplier of auto emission testing centers which we have included in ambient. It has both process and hand held ambient analyzers for water. However, this segment is not as large as the air segment.

Thermo Fisher is a strong player in all areas. It is the world leader in both ambient and stack gas analyzers, and continues to develop new products. Thermo Fisher Scientific Inc., has announced the new Thermo Scientific IRIS 4600 Mid-IR Laser-Based Nitrous Oxide (N₂O) Analyzer. The IRIS 4600 Mid-IR Laser-Based N₂O Analyzer uses a laser module developed by the recently acquired NovaWave Technologies, Inc, and combines it with proven Thermo Scientific air quality monitoring technology to create the most precise analyzer on the market.

Nitrous oxide is one of the primary greenhouse gases with a greater potential for global warming effects than carbon dioxide (CO₂). The IRIS platform of analyzers is designed for use in monitoring key greenhouse gases (GHG) such as methane and nitrous oxide.

The IRIS 4600 Analyzer uses state-of-the-art mid-infrared laser absorption spectroscopy to simultaneously measure nitrous oxide and water vapor concentrations with high precision and accuracy. Continuous measurement of nitrous oxide gas and water vapor allow for the calculation of the nitrous oxide dry-mole fraction at sub-ppb levels. The analyzer is capable of making measurements in the range 50 to 4000 ppb.

“For nitrous oxide in particular, monitoring concentrations at the 3-micron band is highly desirable, as the associated absorption intensity is nearly 100-times stronger than those of the more commonly used 1.5 micron overtone bands,” said James Scherer, director, business development, Thermo Fisher. “Additionally, the DFG laser platform leverages telecom commodity technologies instead of MIR approaches, which have yet to find high-volume applications. As such, the sensor can be manufactured with high yield, reproducibility and reliability.”

In 2010 – Teledyne Technologies Incorporated announced the formation of the Teledyne Water Quality Group. This group represents six of Teledyne’s market-leading companies focused on providing measurement and analytical solutions for water and water-related markets. The following Teledyne companies are part of the Teledyne Water Quality Group:

Teledyne Monitor Labs is a supplier of environmental monitoring instrumentation for the detection, measurement, and reporting of air pollutants. It has over 30 years experience in providing state-of-the-art Continuous Emissions Monitoring products to a wide variety of industrial markets.

Danaher is primarily in the water segment and not air. Its acquisition of Hach resulted in a leading position in water. The Environmental segment provides products that help protect water supply and air quality and serves two primary markets: water quality and retail/commercial petroleum. The water quality business is a global leader in water quality analysis and treatment, providing instrumentation and disinfection systems to help analyze and manage the quality of ultra-pure, potable and wastewater in residential, commercial and industrial applications. The retail/commercial petroleum business is a leading worldwide provider of products and services for the global petroleum market. Solutions and services are focused on fuel dispensing point-of-sale systems, payment systems and environmental compliance.

Emerson emphasizes continuous analyzers for both air and water processes. It offers a complete range of analyzers, transmitters, and sensors for the continuous on-line measurement of pH, ORP, conductivity, dissolved oxygen, ozone, chlorine, and turbidity.

Its sensors and analyzers are used extensively in the chemical process, food & beverage, power, mineral processing, petroleum refining, pharmaceutical, primary metals, pulp and paper, semiconductor, textile, water and wastewater industries

Emerson Rosemont oxygen analyzers are widely used in air pollution continuous emissions monitoring systems. Rosemount Analytical also offers the following NO_x Analyzers.

The Model Chemiluminescence 951C NO_x Analyzer features a heated, temperature-controlled, carbon-based converter for NO_x analysis.

The NGA 2000 CLD NO/NO_x analyzer module, the industry's first modular chemiluminescence analyzer, provides quick and accurate measurement of oxides of nitrogen (NO/NO_x) over a wide dynamic range from 0 to 10 ppm through 0 to 10,000 ppm.

Rosemount Analytical's NGA 2000 Wet Chemiluminescence Detection Analyzer Module (WCLD) is the industry's first modular analyzer designed to meet stringent environmental regulations on NO_x emissions

ABB is the world's leading manufacturer in the field of continuous gas analysis and system solutions - formerly known as Hartmann & Braun.

ABB also offers a wide range of products for the water industry, including drives, motors, instrumentation, low voltage products, medium voltage products and SCADA/DCS systems.

Endress & Hauser has a wide range of instruments for liquids and gases. It has announced plans to further expand its Greenwood, IN, campus with additional manufacturing and support capabilities. The $40-million development project includes a 100,000 sq ft plant that will be connected to the existing magnetic flowmeter building, and a new 100,000 sq ft manufacturing plant. Production at both of the new manufacturing facilities is planned to start in 2013.

The new Coriolis mass flowmeter plant will produce flowmeters for customers throughout the Americas. Coriolis mass flowmeters provide highly accurate measurement of liquids and gases critical in many process applications.

The new level and pressure instrument plant will facilitate improved logistics, as well as increased throughput to accommodate sales growth in radar level transmitters and pressure transmitters.

Endress & Hauser opened a new magnetic flowmeter building in 2007. Just six months ago, the company announced the opening of its new 12,000 sq ft manufacturing plant to build thermowells, transmitters, recorders, flow computers, safety barriers, displays and other instrumentation to meet the increasing demand for Endress & Hauser instrumentation in North America and South America.

Endress & Hauser also builds analytical instrumentation at their facility in Anaheim, California where expansions have recently taken place.

Today, more than 90% of products that Endress & Hauser ships to its U.S. customers are built in the U.S. This expansion will allow Endress & Hauser to further build on its capabilities to support customers with the products, support, and services they need to meet ever-increasing market challenges.

Swan Analytical is a manufacturer of on-line analytical instruments for water analysis in applications such as high purity water, steam, condensate, cooling water, potable water and effluent. Swan instruments measure a number of parameters within these applications such as turbidity, chlorine, sodium, dissolved oxygen, pH, ORP and others. It is not active in the air segment.

Honeywell offers a complete line of water quality instruments including flow pH, conductivity, dissolved oxygen. It also offers the supporting control systems. With its acquisition of MDA some years ago it also became a leader in the toxic gas measurement segment.

Xylem is a new company formed by the splitting of ITT. It is focused on water. Through a number of acquisitions it has become a major supplier of water instrumentation. Its subsidiaries include YSI, OI, and WTW

The YSI IQ SensorNet 2020 XT is a modular water quality system for a complete sensor network ideal for various installation needs. The modular system can accept additional sensors easily at any time. This is a powerful system to continuously measure water quality parameters anywhere in a facility for process control.

Immediate benefits include better network visibility and management, early detection of network failures, improved compliance with regulatory targets and cost savings (energy, pump/blower maintenance, labor).

The entire system accommodates up to 20 sensors for the above listed parameters in any combination. Any sensor can also be changed out at any time without re-wiring if another parameter is needed. Simply change sensors (parameters) and start getting data for the new parameter.

Harper’s ground-breaking Beacon™ program offers carbon fiber manufacturers the ability to evaluate the carbon footprint of their manufacturing process and identify opportunities for improvement.

With its extensive experience in the industry since the market’s inception, Harper has developed a model that analyzes various line sizes, precursors, integration scenarios and energy recovery options and ranks the environmental impact of the process line, whether existing or planned. The program generates facility-specific metrics to be compared against a common industry baseline and then utilizes the information to develop improvement plans to drive greater energy recovery and lower operating costs.

The carbon fiber industry is on the cusp of reaching adoption in several key markets, such as automotive, that will set the path for the future of the industry. The company will focus on achieving greatest output cost effectively with environmental responsibility in order to secure widespread utilization.

The Beacon model is a complex analysis of over one hundred integrated line design parameters. Beacon defines the range of carbon footprints created by various process integration strategies and then ranks the environmental impact of those process variations as a function of scale operation, taking into account line size, production rate, integrated heat recovery and emissions controls.

Harper’s Beacon process goes further to then analyze equipment features and integration parameters in each step of the process, including oxidation, carbonization, and graphitization, and propose design improvements to yield increased energy efficiencies. Major aspects are considered, including choice of utilities, impact of retention times, packing efficiency, use of energy recovery such as preheated air, selection of waste gas handling and treatment systems, and more. The endeavor to incorporate the impact of waste gas handling was achieved with inputs from industry experts in emissions abatement such as Anguil Environmental Systems.

Type of Source		CO	PM
			Coal, Biomass or Residual Oil (excludes Light Oil): Design Heat Rate Input Capacity
			10 to 250 MMBtu/hr		≥250 MMBtu/hr
			Wet Scrubber	No Wet Scrubber	≥250 MMBtu/hr
Major Source	New or Existing	O₂ CEMS		COMS	PM CEMS
Area Source: Coal	New	O₂ CEMS		COMS	COMS
Area Source: Coal	Existing	O₂ CEMS
Area Source: Biomass or Oil	New			COMS	COMS
Area Source: Biomass or Oil	Existing

	March 2010 Proposed Rule	June 2011 Final Rule	December 2011 Reconsideration Proposal
Major Source	CO CEMS	O₂ CEMS	Oxygen trim system

CEMS Revenues	($ Millions)
Africa	23
CIS	19
East Asia	402
Eastern Europe	36
Middle East	79
NAFTA	249
South & Central America	37
West Asia	36
Western Europe	112
TOTAL	993

Company	Air		Water
	Stack/Process	Ambient	Process	Ambient
Horiba	x	x	x	x
Thermo Fisher	x	x	x	x
Teledyne	x	x	x	x
Danaher			x	x
Emerson	x		x
ABB	x		x
Endress & Hauser	x	x	x	x
Swan			x	x
Honeywell	x		x
Xylem			x	x